The Backhaul from the Collector Meters (Cell Relays) to SCE back-office uses 4G Cellular services provided by Verizon and employs the CDMA protocol

$0

Meter communications network

Meter to Meter and Meter to Collector (Cell Relays) uses 900 MHz communications in the ISM band and uses Itron's RF Mesh protocol.

Head end server

The head-end System is Itron's OpenWay system. The primary component is the Network Management System (NMS) also known as the Data Collection Engine (DCE). The function of the NMS is to pass through meter data (e.g. consumption), events and 2 -way communications between the meters and MDMS. Other tasks performed by the NMS include managing meter configurations, managing groups of meters and supporting interactive reads of individual meters for diagnostics purposes.

$1,257,691

Meter data analysis system

All meter data are collected through the Network Management System and stored in an Oracle relational database.

Other IT systems and applications

Not Applicable to Project

Web portal deployed and operational

Quantity*

Description

Customers with access to web portal

0

Customers enrolled in web portal

0

Each home gateway is capable of displaying a web portal. The portal can be accessed through a computer application on the customer's local network.

Customer systems installed and operational

Quantity*

Description

Cost

Communication networks and home area networks

N/A

A HAN is a network established in the home to enable access, control and operation of devices, appliances, air conditioners, etc. In this project the ZigBee Smart Energy Profile 1.1 protocol is used for the HAN network.

N/A

In home displays

22

In-home displays provide consumers with comprehensive information about their energy consumption, including:
current household energy use in both kilowatts and dollars-per-hour, daily energy cost (including comparison to previous days cost), cost of electricity in real time, monthly bill tracking with up-to-date billing information and an estimated end-of-month bill and demand response event messages.

$7,020

Energy management device

22

EMSs control loads in the home and centralize operation and control of other HAN devices. They typically function as gateway or hub and can be accessed locally in the HAN or remotely through the meter or the Internet. EMS devices will be evaluated in this project.

N/A

Direct load control devices

0

NA

$0

Programmable communicating thermostats

31

PCTs are capable of communicating wirelessly with the HAN and enable customers to take advantage of AC DR pricing programs.

$9,610

Smart appliances

64

Smart appliances are capable of receiving signals from the AMI HAN and can react to DR commands from an AMI load control system. Smart appliances evaluated for this project include refrigerators, dishwashers, and clothes washers.

$137,428

Customer system communication networks

Description

Network characteristics within customer premise

A HAN is a network established in the home to enable access, control and operation of devices, appliances, air conditioners, etc. In this project the ZigBee Smart Energy Profile 1.1 protocol is used for the HAN network.

Distributed energy resources

Quantity*

Capacity

Description

Cost

Distributed generation

23

108 kW

- All distributed generations are all solar photovoltaic systems. The sizes vary by the amount of PVs installed on various homes.
- The RESUs are comprised of automotive-grade lithium ion cells, have nominal continuous power output ratings of 4kW, and usable stored energy of at least 10 kWh.
- The CES is comprised of lithium ion cells. The CES device is sized for 25kW power output and 50kWh energy capacity.
- The subproject 2 battery energy storage system is comprise of lithium ion cells and it is sized for 100 kW power output and 100 kWh energy capacity.
- Electric Vehicle Supply Equipment is used to support charging of plug-in electric vehicles in the home. This equipment has the capability to communicate with local smart meters to exchange DR messages. EVs and EVSEs will be tested and evaluated under various scenarios, including load control.

$843,530

Energy storage

16

181 kW

$1,850,130

Plug in electric vehicle charging points

44

328 kW

$234,022

Distributed energy resource interface

N/A

N/A

NA

$0

Electric distribution system

%

Description

Portion of distribution system with SCADA due to SGIG/SGD program

0.00%

Not Applicable to Project

Portion of distribution system with DA due to SGIG/SGD program

0.00%

Not Applicable to Project

DA devices installed and operational

Quantity*

Description

Cost

Automated feeder switches

0

Not Applicable to Project

$0

Automated capacitors

15

$0

Automated regulators

0

$0

Feeder monitors

0

$0

Remote fault indicators

0

$0

Transformer monitors (line)

0

$1,196,949

Smart relays

0

Fault current limiter

0

$0

Other devices

0

$0

SCADA and DA communications network

Cost

Communications equipment and SCADA

$0

Distribution management systems integration

Integrated

Description

AMI

No

The distribution management system (DMS) is used by system operators to monitor and control the distribution system. The DMS will also be used to monitor and display status of the Universal Remote Controlled Interrupters (URCI) to system Operators and provide manual override operation if needed. The DMS will also be used to control distribution capacitors and provide capacitor voltage readings to the Advanced Volt Var Control application, optimizing customers' voltage to reduce energy consumption.

Outage management system

No

Not Applicable to Project

Distributed energy resource interface

No

Residential Energy Storage Units (RESU) connect via internet connection to a server accessible on the network. A utility interface is hosted on this server showing detailed information regarding both current status and history of each of RESUs activity. This interface is a web page accessible in a standard browser. Some of the information viewable includes: the power being dispatched or drawn from or to the grid, the PV power passing through each unit, the energy available in each RESU, the reactive power of each unit and a log of errors and events on each system. This interface allows the utility to group the RESUs and control them in bulk. From this interface, the utility can send Demand Response events specifically to a group of RESUs, set up a specific charging or discharging schedule, enter any of the Smart Modes built in to the devices, and enable or disable Reactive Power Support.
The Community Energy Storage (CES) is controllable and accessible through a SCADA interface utilizing DNP3 communication. A Distributed Energy Management (DEM) server communicates with the CES via this SCADA connection to log data and allow remote control of the system. The DEM displays voltages, power (real and reactive), battery energy, and monitors CES system alarms. ISGD CES operators use the DEM to send operating commands, including setting up a daily charge and discharge schedule. The DEM also allows control over the islanding behavior of the CES; this can be inhibited or manually triggered as desired.

Other

No

Not Applicable to Project

Distribution automation features / functionality

Function enabled

Description

Fault location, isolation and service restoration (FLISR)

No

Not Applicable to Project

Voltage optimization

Yes

Distribution Management System will be used to control distribution capacitors and provide capacitor voltage readings to the Advanced Volt Var Control application which would optimize customers' voltage to reduce their energy consumption.

Feeder peak load management

No

Not Applicable to Project

Microgrids

No

Not Applicable to Project

Other functions

No

Not Applicable to Project

* In some circumstances, costs are incurred before devices are installed resulting in a reported cost where the quantity is zero.

* All dollar figures are the total cost, which is the sum of the federal investment and cost share of the recipient (the recipient cost share must be at least 50% of the total overall project cost).

** In some cases the number of entities reporting is greater than the total number of projects funded by the Recovery Act because some projects have multiple sub-projects that report data. View list of sub-projects.

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